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Enron Mail |
A few of our subscribers did not receive the EMR on Friday, so we are resending in case there was an unforeseen server error. We apologize for any inconvenience. -EMR staff Energy Market Report Friday, January 11, 2002 *See attached pdf file. __________________________________________________________ Western Pre-Scheduled Firm Electricity Prices($/MWh) January 11, 2002 for January 13, 2002 Peak(Heavy) Low Change** High Change** NW/N. Rockies* 16.00 NA 17.25 NA Mid-Columbia* 16.00 NA 17.25 NA COB* 15.00 NA 17.75 NA N. California* 15.00 NA 18.00 NA Midway/Sylmar* NA NA NA NA S. California* 14.50 NA 19.50 NA Mead* 16.50 NA 18.00 NA Palo Verde* 15.00 NA 18.25 NA Inland SW* 15.00 NA 18.25 NA 4-Corners* 15.00 NA 16.50 NA Central Rockies* 12.75 NA 14.50 NA __________________________________________________________ Off-Peak(Light) Low Change** High Change** NW/N. Rockies* 16.00 NA 17.25 NA Mid-Columbia* 16.00 NA 17.25 NA COB* 15.00 NA 17.75 NA N. California* 15.00 NA 18.00 NA Midway/Sylmar* NA NA NA NA S. California* 14.50 NA 19.50 NA Mead* 16.50 NA 18.00 NA Palo Verde* 15.00 NA 18.25 NA Inland SW* 15.00 NA 18.25 NA 4-Corners* 15.00 NA 16.50 NA Central Rockies* 12.75 NA 14.50 NA *Denotes trading of flat, 24-hour products. **"NA" changes are not applicable because prices for on and off peak goods are not comparable to flat products. __________________________________________________________ Western Pre-Scheduled Firm Electricity Prices($/MWh) January 11, 2002 for January 14, 2002 Peak(Heavy) Low Change** High Change** NW/N. Rockies 18.50 NA 19.25 NA Mid-Columbia 18.50 NA 19.25 NA COB 19.50 NA 21.50 NA N. California 21.00 NA 22.50 NA Midway/Sylmar NA NA NA NA S. California 21.50 NA 23.00 NA Mead 21.00 NA 21.75 NA Palo Verde 20.25 NA 22.25 NA Inland SW 20.25 NA 22.25 NA 4-Corners 20.50 NA 21.00 NA Central Rockies 18.75 NA 21.00 NA __________________________________________________________ Off-Peak(Light) Low Change** High Change** NW/N. Rockies 16.00 NA 17.25 NA Mid-Columbia 16.00 NA 17.25 NA COB 15.00 NA 17.75 NA N. California 15.00 NA 18.00 NA Midway/Sylmar NA NA NA NA S. California 14.50 NA 19.50 NA Mead 16.50 NA 18.00 NA Palo Verde 15.00 NA 18.25 NA Inland SW 15.00 NA 18.25 NA 4-Corners 15.00 NA 16.50 NA Central Rockies 12.75 NA 14.50 NA **"NA" changes are not applicable because prices for on and off peak goods are not comparable to flat products. __________________________________________________________ Misery Loves Company Heavy load energy costs in the Western U.S. rose for Monday delivery on expectations of more weather-related demand at the start of the new week, as well as on the usual premium that occurs when scheduling three days out. Several players expected more strength later in the week when temperatures were forecast to dip even further. Some parties also claimed that a rise in the number of unit outages could play a role in strengthening the daily electricity market. "It was a pretty boring day in the spot electricity market, there was no volatility and no liquidity. But next week could prove to be a bit more exciting if the cold weather materializes," said one marketer on Friday. Following last Monday's auction for a 51 percent ownership stake in the company's trading arm, Enron Corp. chose to have Swiss Bank UBS Warburg take control of its main energy trading business. Enron declined to say how much UBS is paying, but company lawyers said they will release details of the winning bid to a New York bankruptcy judge on Monday. The move was designed to restore market confidence in the one-time gas and electricity marketing giant. Enron shares were suspended since the NYSE opened on Friday, pending news on the deal. Andersen, the accounting firm for Enron, remains in hot water following news that the firm violated one of the accounting profession's basic auditing standards by destroying several Enron documents. There are still many questions surrounding the destroyed documents, including who shredded them, when, and exactly why. The issue has without doubt tarnished the reputation of the accounting firm, all for the sake of Enron. Misery loves company. Heavy load energy costs in the Northwest rose by as much as 2$/MWh for power to be delivered on Monday, largely the result of forecasted cooling over the weekend, which was likely to boost demand early in the new week. "We're going to drop back down to more seasonable temperatures over the weekend, and that means we'll have more heating to contend with," said one Northwest utility trader. Light load goods rose by an average of 2.5$/MWh on the anticipated cooling, and partly due to the inclusion of the all-day Sunday piece. Flow forecasts for Chief Joseph remained healthy despite a reduction in runoff, coming in at 60 kcfs Saturday, 50 kcfs Sunday, 95 kcfs Monday, and 90 kcfs Tuesday through Friday. In unit news, Colstrip #4 (700 MW) was back on the grid Friday, but Colstrip #3 (700 MW) was brought down due to "generator problems." While no official ETR was available, sources were hearing a January 18 return, "at the earliest." Reports indicated that Wyoming-based Dave Johnston #3 (230 MW) has been down since January 8, and the return date, which currently sits at January 15, has been pushed back several times. Finally, Bridger #3 (520 MW) was scheduled to shut on Saturday, January 12 for tube leak repairs. While no official ETR was available, conventional wisdom suggests a 48 to 72-hour turnaround. Weather forecasts for Seattle and Portland were calling for temperatures to dip to normal levels over the weekend, while the latest six-to-ten from the NWS was predicting a near-blanketing of below-normal temperatures across the entire region from January 17 to 21. Despite little change in temperature forecasts for Monday and weaker gas prices at the Socal border, electricity prices for the Sunday/Monday package settled higher in the Golden State on Friday. "Sunday's inclusion usually brings light load prices up, but light load ran up more than I expected at the end, maybe on the number of units off for the weekend and the colder weather anticipated in the new week," said one California trader. On-peak power at SP15 traded between 21.5 and 23$/MWh, while off-peak deals were done from 14.5 all the way up to 19.5$/MWh, gaining more than 4$/MWh on the high end. In unit news, Etiwanda #4 (320 MW) returned to the grid on Friday, as did larger gas unit Pittsburg #7 (682 MW), down since January 3 for unplanned maintenance. Off-and-on Moss Landing #6 (739 MW) came down for unplanned maintenance, while Encina #5 (332 MW) exited for planned repairs. Forecasts at mid-state load centers called for temperatures in the 42 to 57 degree range on Monday, about five degrees above normal for this time of year. Los Angeles was anticipating highs around 67 degrees and overnight lows at 51 degrees on Monday, right at seasonal levels. The most current six-to-ten called for below-normal temperatures from January 17 to 21. Day-ahead prices in the Southwest made their typical rise for Sunday/Monday power, but some parties were surprised by the amount of strength seen. "Prices were up quite a bit, which surprised me since spot gas was off slightly today and while temperatures are expected to drop, they should still remain above normal levels," said one Phoenix-based player. Peak power at Palo Verde traded from 20.25 to 22.25$/MWh, with the bulk of deals done at the 21$/MWh mark. Light load goods ranged from 15 to 18.25$/MWh, with unconfirmed trades heard as low as 13$/MWh. In unit news, Arizona-based Coronado #1 (365 MW) remained off line Friday, but was expected to ramp up to two thirds load on Saturday, where it will remain for more repairs until ramping up to full power on January 16. While most regional temperatures were expected to remain above or just at normal levels into the new week, the latest six-to-ten was predicting a round of below-normal temperatures for the entire desert region from January 17 to 21. Patrick O'Neill and Jessie Norris _________________________________________________________ Western Generating Unit Outages Current Begins Ends Reason CAISO units <250/6139 total NA NA planned/unplanned* Alamitos #3/320/gas 04-Dec-01 ? planned Alamitos #4/320/gas 04-Jan-02 ? planned Bridger #3/520/coal 12-Jan-02 14-Jan-02 tube leak* Colstrip #3/700/coal 11-Jan-02 ? repairs* Coronado #1/365/coal 22-Dec-01 11-Jan-02 main transformer Encina #5/332/gas 11-Jan-02 ? planned* Etiwanda #3/320/gas 22-Dec-01 ? planned Four Corners #5 09-Jan-02 14-Mar-02 maintenance Grand Coulee #19/600/hydro 10-Dec-01 March repairs Haynes #6/341/gas 07-Jan-02 ? planned Helms PGP #2/407/hydro 01-Oct-01 ? planned Hyatt/Thermalito/933/hydro 02-Oct-01 ? @607 MW, unplanned Morro Bay #3/337/gas 04-Jan-02 ? planned Moss Landing #6/739/gas 11-Jan-02 ? unplanned* Moss Landing #7/739/gas 29-Dec-01 ? planned Ormond Beach #1/725/gas 28-Dec-01 ? planned Ormond Beach #2/750/gas 05-Oct-01 ? @350 MW, unplanned Pittsburg #6/317/gas 22-Nov-01 ? planned Redondo #8/480/gas 09-Dec-01 ? planned San Juan #4/534/coal 10-Jan-02 13-Jan-02 tube leak* For unit owners refer to pdf version. *Indicates a change from previous EMR. ______________________________________________________________________ Eastern Markets Pre-Scheduled Firm Power Prices ($/MWh) January 11, 2002 for January 14, 2002 Peak (Heavy) in $/MWh Low Change High Change Into Cinergy 16.50 0.75 18.15 -1.60 Western PJM 24.55 1.80 25.10 2.05 Into Entergy 17.40 2.40 19.00 0.00 Into TVA 18.00 1.50 19.00 0.75 ___________________________________________________________ With cooler weather forecast for Monday and a stronger gas market for much of the day, spot electricity prices traded mostly higher and in tighter ranges on Friday across the Eastern Interconnect. However, power prices for February delivery were mostly down, reflecting a still predominantly bearish and cautious market. NYMEX Henry Hub natural gas futures had posted gains on Friday, mainly on weekend risk. The front-month contract edged up 1.9 cents to close at 2.204$/mmBtu, while March picked up an incremental 0.8 cent to end at 2.203$/mmBtu. An upturn in the gas market, cooler temperatures for the new week, and stronger real-time prices for much of the day all helped boost peak power prices for Monday delivery in the Mid-Atlantic on Friday. Western PJM goods were bought and sold between 24.55 and 25.1$/MWh, gaining about 2$/MWh at both ends. February deals were heard from 25.4 to 25.5$/MWh. LMPs spent an hour or more above 37$/MWh on three occasions during the day on Friday, bringing the average up to 25.11$/MWh through 15:00 EST, a substantial gain over Thursday's average. Traders thought an unexpected outage at one of the Salem units (1,106 MW) was the most likely culprit sending the dailies and real-time prices higher. Sources also thought the unit would remain down into the early part of the new week. Forecasts for Monday called for temperatures to remain above normal but below Friday's readings. Highs were expected in the 47 to 50 degree range, but lows were expected to dip into the low-30s, prompting expectations of more overnight heating load in the new week. The most current six-to-ten predicted below-normal conditions from January 17 to 21. Heavy load electricity prices traded mostly steady and in a narrower range to a day ago in the Midwest on Friday. Into Cinergy pieces changed hands between 16.5 and 18.15$/MWh. Although the high end was significantly lower, the bulk of transactions were seen near Thursday's levels. The February contract continued to bleed on Friday, with trades heard between 20.9 and 21.3$/MWh. "February is hopefully near the low end of where it can trade, but the physical market is weak, so it all depends on how weather forecasts and gas do next week," commented one forwards trader. In unit news, Michigan-based Cook #2 (1,090 MW) was operating at 90% on Friday, joining fellow nuke LaSalle (1,144 MW) in coasting down towards mid-month refueling outages. Temperatures were expected to remain above normal on Monday, with highs reaching the low-40s and lows mostly in the upper-20s. The latest six-to-ten called for below-normal temperatures from January 17 to 21. Bouyed up by gas gains, peak power prices were steady to slightly higher on Friday in the Southeast. No new outages were reported on Friday. Temperatures were expected to cool somewhat in the new week, but ample generation kept prices in check. Highs for Monday and Tuesday were expected in the mid-50s. The most current six-to-ten called for below-normal temperatures from January 17 to 21. ___________________________________________________________ California ISO Congestion Index in $/MWh Path Peak Off-peak for 12-Jan-02 NW1 to NP15 0.00 0.00 NW3 to SP15 0.00 0.00 AZ3 to SP15 0.00 0.00 LC1 to SP15 0.00 0.00 SP15 to NP15 0.00 0.00 OTC Forward Peak Electricity Contracts in $/MWh Mid-C PV SP-15 Bid Ask Bid Ask Bid Ask BOM 18.00 19.00 20.00 21.00 21.50 22.50 February 18.50 20.00 21.25 22.25 23.00 24.00 March 17.00 18.50 21.50 22.50 22.75 23.75 April 17.00 18.50 23.00 24.00 23.00 24.00 Q2 '02 16.50 18.00 25.25 26.25 25.00 26.00 Q3 '02 30.00 31.50 39.00 40.00 38.00 39.00 Q4 '02 25.75 27.25 26.00 27.00 27.50 28.50 Q1 '03 25.00 26.50 26.00 27.00 28.00 29.00 Cal '03 26.00 27.50 30.00 31.00 32.00 33.00 Represents the most recent bid/ask spread obtainable by the Energy Market Report. Alberta Power Pool Index (C$/MWh) Peak(14) Peak(16) Off-Peak Flat Change for 10-Jan-02 38.14 37.45 14.47 30.53 -1.24 BPA's Offer for 01/15/02. Hours Amount NW delivered COB/NOB delivered 7-22 100MW Market Price* Market Price* 1-6, 23-24 100MW Market Price* Market Price* *Market price will be determined at time of request. NYMEX Henry Hub Gas Futures in $/mmBtu Close Change Feb 2.204 0.019 Mar 2.203 0.008 Natural Gas Spot Prices in $/mmBtu Low High Sumas 1.95 2.00 So. Cal Border 2.10 2.16 San Juan 1.97 2.02 __________________________________________________________ Economic Insight, Inc. - 3004 SW First, Portland, Oregon 97201, Telephone (503) 222-2425, Internet e-mail emr@econ.com - Copyright, Economic Insight, Inc. 2002.
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